Subsurface tubing safety valve with auxiliary operating means

ABSTRACT

A subsurface tubing safety valve, for wells, in which a sleeve is held in a first position and shiftable to a second position by a shifting tool. The safety valve is held open by control fluid pressure supplied from the top of the well and is closeable by well fluid pressure when control fluid pressure is reduced. When the shiftable sleeve is moved to its second position, it also opens the safety valve and forms a seat for an auxiliary wireline safety valve adapted to be held open by control fluid pressure and closed by well fluid pressure.

[451 July 29, 1975 United States atent Crowe 7/1972 Kanady 7/1973 Mott l l/ 1963 Fredd ABSTRACT 17 Claims, 32 Drawing Figures Primary ExaminerJames A. Leppink Attorney, Agent, or FirmBernard Kriegel A subsurface tubing safety valve, for wells, in which a sleeve is held in a first position and shiftable to a second position by a shifting tool. The safety valve is held open by control fluid pressure supplied from the top of the well and is closeable by well fluid pressure when control fluid pressure is reduced. When the shiftable sleeve is moved to its second position, it also opens the safety valve and forms a seat for an auxiliary wireline safety valve adapted to be held open by control fluid pressure and closed by well fluid pressure.

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In the production of well fluids, such as oil and/or gas, from wells, it has been the practice to provide automatically closeable shutoff or saftey valves which are located downhole in the well and are held open by control fluid pressure, the valves closing automatically when control fluid pressure is purposely reduced to allow the valves to close or damage occurs to the-control fluid system at the well head or on an offshore platform. I

Such valves are employed below the well head, and in the case of offshore wells the valves are installed below the mudline at such depth as may be desired or established by regulation, so that in the event of damage to the well caused by shifting earth or subsidence, the wells can be shut in to avoid loss of valuable well fluids into the water and, also, to avoid contamination of the water and the shore.

Many offshore wells are produced from spaced well zones through separate strings of production tubing, and a safety or shutoff valve is required for each zone. Since, from time to time, it is necessary to perform various remedial operations through the tubing strings, it is preferred that the safety valves have a full bore opening which will allow wireline tools to pass through the safety valves. On the other hand, it is also preferred that the safety valves be easily removed from the well for service or repair. While safety valves adapte'd to be run into the well and landed in a seat on a wireline and retrieved on wireline are relatively simple to run and retrieve without requiring that the tubing string be pulled from the well, such wireline valves, in general, do not have a full bore opening through which remedial operations can be performed through the production tubing, particularly if the well is cased with comparatively small casing so that the valves must be small in diameter.

Full opening valves have been made up in the tubing strings and run into the well in the tubing string. Accordingly, repair or service of such tubing string safety valves has required that the entire tubing string be ently imposed on the size of the tubing valves that can-- be run into the well on tubing, as well as on wireline.

ln the above identified application of which this application is a continuation-in-part, there is disclosed a plural zone, subsurface safety valve system which is conveniently useful in the control of a.multiple zone well. The subsurface valve assembly is run into the well on upper tubing strings and is landed in a receptacle provided in a tubing hanger which is anchored in the well casing, say, below the mudline of an off-shore well, and supports the major production tubing weight suspended below the tubing hanger. The plural safety valve can readily be retrieved from the tubing hanger without requiring that the entire production tubing string be pulled from the well, and without requiring that the well be killed. However, even though the pullingof the upper tubing strings and the subsurface valve assembly from the tubing hanger may be a comparatively simple task, there is a resultant loss of well production time from the several well zones.

The present invention provides a subsurface safety valve which has a valve member closeable by well fluid pressure and adapted to be held open by control fluid pressure, wherein auxiliary means are also provided for shifting the valve member to the open position by other mechanical means if the control fluid pressure responsive operating means should fail, and it is, nevertheless, desired that the particular earth zone remain on production until the subsurface valve assembly is to be pulled from the well for some other reason.

In addition, the present invention provides a subsurface valve which has means for receiving an auxiliary wireline retrievable safety shutoff valve openable by control fluid pressure from the same source which holds the tubing valve open and closeable by well fluid pressure, whereby the safety function of the subsurface valve means is maintained, until the subsurface tubing valve is otherwise to be pulled.

More particularly, the invention involves providing a subsurface shutoff valve for production tubing, wherein control fluid pressure is admitted to a pressure chamber and acts on a piston area of the tubing valve to overcome well fluid pressure and hold the tubing valve open. This pressure chamber is separated from the main valve passage by a sealing sleeve which normally closes a port leading between the pressure chamber and the main valve passage. The sleeve is releasable for movement to a second position at which the normally closed port is open. A wireline retrievable shutoff valve can then be landed in the sealing sleeve and then opened by control fluid pressure supplied through the opened port.

Means normally retain the sealing sleeve in its first position and are releasable to allow movement of the sleeve to its second position and a shifting tool is adapted to be removably seated in the tubing valve and operated by fluid pressure supplied to the tubing to actuate the sealing sleeve to its second position. When the shifting tool is removed, the sleeve is held by latch means in its second position for reception of-the auxiliary wireline safety valve.

The tubing valve has' equalizing means enabling the equalization of pressure across the tubing valve when it is closed, whereby opening of the tubing valve is easier due to the reduction in friction whch must be overcome. The equalizing means includes a passage which is closed by back flow preventing valve means when the wireline valve is in place in the tubing valve so that control fluid cannot flow into the bypass passage.

In accordance with one form of the invention, the auxiliary shutoff valve has longitudinally spaced seals which engage within spaced sealing regions of the tubing hanger body, so as to span the control fluid pressure regions of the tubing hanger, thereby preventing leakage in the event of seal failure.

This invention possesses many other advantages, and has other purposes which may be made more clearly apparent from a consideration of a form in which it may be embodied. This form is shown in the drawings accompanying and forming part of the present specification. It and its method of use will now be described in detail for the purpose of illustrating the general principles of the invention; but it is to be understood that such detailed description is not to be taken in a limiting sense, since the scope of the invention is best defined by the appended claims.

Referring to the drawings:

FIG. 1 is a diagrammatic illustration showing dual safety valve apparatus installed in a tubing hanger anchored in a well casing extending through vertically spaced productive well zones which are isolated from one another by packers, and from which well fluids are produced through a pair of production tubing strings;

FIGS. 2a, 2b, 2c, and 2d, together, constitute a view generally in elevation, but with certain parts broken away, showing the subsurface valve assembly landed in the tubing hanger, FIGS. 2b through 2d, respectively, constituting successive downward continuations of FIG. 2a;

FIG. 3 is a view partly in elevation and partly in section, as taken on the line 3-3 of FIG. 2d;

FIG. 4 is a horizontal section, as taken on the line 44 of FIG. 2b;

FIG. 5 is a horizontal section as taken on the line 5-5 of FIG. 2d;

FIG. 6 is a horizontal section, as taken on the line 6-6 of FIG. 2d;

FIG. 7 is a horizontal section, as taken on the line 77 of FIG. 2a;

FIG. 8 is a horizontal section, as taken on the line 8-8 of FIG. 2b;

FIGS. 9a and 9b, together, constitute a vertical section through one of the subsurface valve assemblies, as taken on the line 99 of FIG. 7, FIG. 9b constituting a downward continuation of FIG. 9a, and the valve being shown in the normally closed condition;

FIGS. 10a and 10b, together, constitute a view generally corresponding to FIGS. 9a and 9b, but showing the valve assembly in the open condition;

FIG. 11 is a horizontal section, as taken on the line 1111 of FIG. 9a;

FIG. 12 is a horizontal section, as taken on the line 12-12 of FIG. 9a;

FIG. 13 is a fragmentary horizontal section, as taken on the line 13--13 of FIG. 9b;

FIG. 14 is a fragmentary vertical section, as taken on the line 1414 of FIG. 7;

FIG. 15 is an exploded detail view in perspective, showing a typical ball valve and a removable side closure and valve supporting member;

FIG. 16 is a fragmentary detailed view partly in elevation and partly in section showing the ball valve in a closed position;

FIG. 17 is a view generally corresponding to FIG. 16, but showing the ball valve shifted longitudinally downwardly from engagement with the resilient seal but prior to rotation towards the open position;

FIG. 18 is a view corresponding to FIGS. 16 and 17, showing the ball valve rotated towards an open position;

FIG. 19 is a view corresponding to FIGS. 16 through 18, but showing the ball valve in the full open position;

FIGS. 20a and 20b, together, constitute a vertical section, with certain parts shown in elevation, showing a shifting tool disposed in a valve assembly with the valve in the closed position prior to movement of the valve to the open position by the shifting tool, FIG. 20b constituting a downward continuation of FIG. 20a;

FIGS. 21a and 21b, together, constitute a view generally corresponding to FIGS. 20a and 20b, but showing the valve shifted to the open position by the shifting tool, and the valve being locked open;

FIGS. 22a and 22b, together, constitute a vertical section with certain parts shown in elevation and showing a wireline retrievable shutoff valve seated and locked in the bore of the locked open main shutoff valve; and

FIGS. 23a and 23b, together, constitute a vertical section with certain parts shown in elevation showing another form of wireline retrievable shutoff valve seated in the locked open main shutoff valve.

As seen in the drawings, the invention is shown in a plural safety valve for an offshore well. Referring first to FIG. 1, as well bore W extends downwardly into the earth below the ocean floor F through vertically spaced well fluid producing zones Z1 and Z2. A casing C is set in the well bore and perforations P in the casing establish communication between the productive zones Z1 and Z2 and the casing C. Set in the casing C is an upper packer P1 located above the productive zone Z1 and a lower packer P2 located in the casing between the productive zones Z1 and Z2. A first production tubing string T1 extends through the packer P1 and opens into the casing therebelow to communicate with the productive zone Z1, and a second production tubing string T2 extends downwardly through the upper packer P1 and downwardly through the lower packer P2 into the casing therebelow for communication with the productive zone Z2. The tubing stings T1 and T2 may extend a number of thousands of feet downwardly in the casing to the packers P1 and P2 and the tubing string T1 and T2 are supported by tubing hanger means TH which is set or anchored in the well casing and forms a seat for a shutoff valve assembly V which comprises dual shutoff valves V1 and V2 for the respective tubing strings T1 and T2. The tubing hanger TH and the valve assembly V are located below the ocean floor or the mudline of a body of water, at a desired or required depth of say 500 to 1,000 feet, more or less. The casing C extends upwardly through the water to a production platform or barge PP, as shown in the diagrammatic illustration. However, as is well known, the well may be completed at the ocean floor and one or a number of additional casings (not shown) may be set in larger diameter well bores, and the casing C may be suspended or hung from a casing hanger located at the ocean floor, in which case, a conductor pipe or other casing (not shown) may extend to the production platform PP. In any event, upper production fluid tubings T3 and T4 extend upwardly from the respective valves V1 and V2 of the valve assembly V and are connected with the usual Christmas Trees CT on the platform PP whereby the flow of well fluids from the well zones Z1 and Z2 may be controlled or manually shutoff. Flow lines FL are provided to conduct well fluids from the Christmas Trees to suitable reservoirs or tanks (not shown).

As will be later described, the respective subsurface valves V1 and V2, which are normally closed, are adapted to be held open, to enable the flow of production fluids therethrough, by means of control fluid pressure supplied through a control fluid conduit CF, or through a pair of such conduits, from a source of control fluid pressure CP. So long as the control fluid pressure is adequate to maintain the subsurface valves V1 and V2 open, well fluids may flow from the zones Z1 and Z2 to the respective flow lines FL, but, if it is desired for any reason to close either of the shutoff valves V] or V2, or in the event of damage of the control fluid tubing, the control fluid pressure may be reduced so that the subsurface valves V1 and V2 are automatically closed, thereby shutting the well in at a location below the ocean floor, to prevent continued production fluid flow.

The tubing hanger assembly TH and the tubing strings T1 and T2 are adapted to be lowered from the platform PP downwardly through the casing C on a setting tool, as more particularly described in the above identified application Ser. No. 243,806, and the valve assembly V is thereafter adapted to be lowered through the casing C into the tubing hanger TH on the upper tubing strings T3 and T4. Likewise, the valve assembly V can be retrieved from the tubing hanger TH, so that under normal circumstances requiring repair or service of the subsurface valve assembly V, it is not necessary to pull the entire dual tubing strings T1 and T2, as has heretofore been the practice. Since only the comparatively short upper tubing strings T3 and T4 need be pulled from the well to remove the valve assembly V, and the substantially longer tubing strings T1 and T2 remain in the well, the platform PP need not be equipped with or supplied with high-powered hoisting apparatus. Instead, the platform PP may simply be provided with a small lowpowered hoist mechanism or a gin pole hoist. In addition, the tubing strings T1 and T2 can be plugged off at or below the tubing hanger TH to enable the service or repair of the valves V1 and V2 without requiring that the well be killed.

As seen in FIGS. 1, 2d, and 5, the tubing hanger TH comprises a body section having an upwardly extended tubular guide section 11, the upper end edge 12 of which is arched downwardly from a peak 13, in op posite directions, to a vertically extended slot 14 at the side of the guide section 11 diametrically opposite the peak 13. Internally of the guide section 11, between the lower end of the slot 14 and the body section 10, is a thread 15 to which a setting tool is connectable, as disclosed and claimed in the companion application Ser. No. 275,911, filed July 28, 1972, for Tubing Hanger Apparatus. Below the internal thread 15 is an internal flange 16 which provides a downwardly facing shoulder 17 for anchoring the valve means V in the hanger TH, as will be later described.

Extending downwardly into the body section 10 from the guide section 11, are a pair of diametrically spaced fluid passages 18, 18 at the upper end of each of which, is a cylindrical receptacle or socket 19. At the lower end of the body section 10, the tubing strings T1 and T2 are connected thereto in communication with the respective passages 18, 18.

Anchor means 34 for the tubing hanger may be as described and shown in the aforementioned application of which this is a continuation-in-part, and comprise suitable slip elements 46 and 47 which are expansible into anchoring engagement with the casing C.

When the setting tool has been removed from the well casing, the tubing hanger assembly is then in condition to receive the dual valve assembly V, as seen in FIGS. 20 through 2d.

The dual valve assembly V, as previously indicated, comprises. in the illustrated embodiment, a pair of valves V1 and V2, since the apparatus is shown as applied to producing from a pair of well zones Z1 and Z2, but it will be understood that the invention is applicable, also, to valve assemblies used in the production of more or less than two well zones.

At its lower end, as seen in FIGS. 2d and 3, the valve assembly V is adapted to be received in the upper tubing hanger body section 11 and to be latched in place by releasable latch means beneath the internal flange 16 in the hanger body section. At diametrically spaced locations in a cross-head 126 of the latch means 125, the latch means 125 has elongated laterally opening spaces 127, 127 accommodating flow tubes 128 and 129 which are respectively adapted to establish communication between the tubing strings T1 and T2 and the valve assemblies V1 and V2, respectively.

At their lower ends, the flow tubes 128 and 129 have sealing end portions 130 and 131, respectively, each having sealing ring means 132 engageable within the bores or receptacles 19 in the tubing hanger body 10. The flow tube 128 extends upwardly from the crosshead 126 and is connected at 133 to a length of tubing 134 which extends further upwardly a suitable distance, and is connected at 135 to the housing 136 of the upper valve assembly V1, which will be hereinafter described. The flow tube 129 also extends upwardly from the cross-head 126 and is connected at 137 to the valve assembly V2, which is spaced vertically downwardly from the valve assembly V to enable utilization of valve assemblies V1 and V2 having full bore flow passages, as will also be later described. Extending upwardly from the valve housing 138 through swivel means 139 is a rotatable tubular member 140 which is connected at its upper end by a coupling 141 to the tubing string T4 above the connection of the tubing string T3 to the valve assembly V1, as seen in FIG. 2a. Rotation of the tubing string T4 and, thus, the tubular member 140 is utilized to engage and release the latch means 126 when the valve assembly V is run into the tubing hanger TH.

The flow tubes are retained in parallel, assembled relation by a vertically split body 142 comprising opposed half sections 143 and 144, as seen in FIG. 6, clamped together by fasteners 145. The body sections 143, 144 have internal grooves 146 which receive annular ribs 147 on the flow tubes 128, 129 to hold the latter against relative axial movement.

When the valve assembly V is being lowered into the tubing hanger TH, a key 148 on one side of the assembly, shown on the flow tube 129, and engageable with the peak 13 of the hanger body section 11 will cause rotation of the valve assembly V, as the key 148 rides downwardly on the inclined surface 12 and is guided into a vertical slot 14, whereby the lower ends 130, 131 of the flow tubes 128, 129 will be properly positioned or oriented so as to be stabbed into the bores or receptacles 19 in the hanger body 11.

The latch means 125 referred to above, comprises a plurality of resilient, normally retracted collett fingers 150 depending from the cross-head 126 and having outwardly projecting latch lugs 151 at their lower ends. The lower ends of the latch fingers 150 are expansible outwardly by a wedge surface 152 on the split body 142 when the cross-head 126 is moved downwardly relative to the body 142, from the position of FIG. 2d to the position of FIG. 3. Means 155 are provided for normally holding the latch fingers 150 in the retracted positions,

and spring means 156 are provided for actuating the cross-head 126 downwardly to cam the fingers 150 outwardly.

More particularly, a pair of bolts 157 extend through the cross-head 126 and have their heads 158 engageable beneath the cross-head 126 to hold the latter in an upper position, as seen in FIG. 2d. These bolts 157 are threaded into a plate 159 which is connected to a pull rod 160, the pull rod extending upwardly alongside the length of tubing 134 and being connected, as seen in FIG. 2b, to a non-rotatable nut 161, having a notch 162 for straddling the tubing 134 to prevent rotation of the nut. The nut 161 has a threaded bore 163, in which a complemental thread 164 on the rotatable tubing section 140 is engaged. Accordingly, when the tubing string T4, which, as previously indicated, is connected to the tubing section 140, is rotated, the nut 161 is moved axially on the tubing section 140, downwardly, from the position of FIG. 2b, to allow downward movement of the plate 159 and the bolts 157.

' The spring means 156 are operable to force the cross-head 126 downwardly and comprises a pair of coiled compression springs 165 disposed about the bolts 157 and seating at their lower ends in bores 166 in the cross-head 126 and at their upper ends against a spring seating plate 167 which abuts beneath the lower valve housing 138. When the cross-head 126 is moved downwardly by the springs 166, the lugs 151 on the latch fingers 150 are cammed by the cam surface 152, ourwardly for engagement beneath the latch shoulder 17 of the tubing hanger body section 11.

As seen in FIGS. 2a through 20, the control fuid conduit CF is connected by a fitting 170 to the upper valve housing 136 of the valve V1 and passage means 171 in the housing 136 conduct control fluid to an outlet fitting 172 which is connected to a conduit 173 leading to an inlet fitting 174 for the lower valve V2. However, if preferred, plural control fluid tubings CF may be employed to supply control fluid pressure to the valves V1 and V2.

The fluid pressure responsive shutoff valve V1 is made according to the invention and is representative of the two valves V1 and V2 and will now be described.

In this form, as seen in FIGS. 9a, 9b, and a, 1017, the valve assembly comprises the outer body 136 and an upper tubular sub 136a which is connected with the lower end of the tubing string T3. The upper body 136a is threadedly connected at 175, at its lower end to the body 136, which, in turn, as previously described, is threadedly connected at 135 to the flow tube 134, which seats in one of the bores or receptacles 19 in the tubing hanger body 10.

A ball valve 176 is disposed within the body 136 and has a passage 177 for the flow of well fluid when the ball valve is in the open position, with the passage 177 aligned with the body 136, the ball valve being rotatable 90, as will be later described, to a closed position, in which flow of well fluid through the body 136 is prevented.

Normally, the ball valve 176 is biased to a closed position by a lower sealing and actuating sleeve 178, which is reciprocable in the valve body 136 between an upper position, as seen in FIG. 9b, and a lower position, as seen in FIG. 10b. The sleeve 178 is piloted in a reduced bore 179 in the body 136, and the lower end of the sleeve extends into a bore 180 in the upper end of the tube 134. A coiled compression spring 181 is disposed between the upper end of the tube 134 and a seating shoulder or ring 182 on the sleeve 178, and biases the sleeve 178 and the ball valve 176 upwardly, Externally, the ball valve 176 has a spherical sealing surface 183 sealingly engageable by a companion sealing end surface 184 at the upper end of the sleeve 178.

Above the ball valve 176 is an upper valve actuating and sealing sleeve 185 having a lower end sealing surface 186, which is complemental to the spherical valve surface 183 of the ball valve 176. At its upper end, the sleeve 185 has an enlarged piston section 187 which is slideably disposed within a cylinder portion 188 of the valve body 136. Below the piston section 187 is a cylindrical section 189 smaller than the outside diameter of the piston section 187. Between the cylindrical section 189 and the cylindrical wall 188 is a sleeve 190 engaged by an external seal ring 191 on the cylindrical section 189 and having an external seal 192 engaging with the cylinder wall 188. At its lower end, the sleeve 190 abuts with an upwardly facing shoulder 193. The difference between the annular cross-sectional area of the sleeve 190 and the annular cross-sectional area of the upper end 194 of the piston section 187 constitutes the net piston area of the piston section 187 exposed, as will be later described, to control fluid pressure to hold the ball valve 176 open. The piston section 187 extends into an annular space 195 defined between the cylindrical wall 188 and a sleeve 196 which is releasably connected by suitable means such as shear screws 197 to a skirt 198 on the lower end of the upper body section 136a, the sleeve 196 carrying a seal ring 199 engageable within the skirt 198, and the skirt 198 having a seal ring 200 engageable in the cylindrical wall 188. This sleeve 196 will be more particularly described hereinafter.

The control fluid passage 171, previously referred to, communicates through a port 201 with the annular space 195 which constitutes a control fluid pressure chamber in which control fluid pressure is operable on the net piston area of the piston section 187 of the sleeve 185 to provide a downward force adapted to overcome the upward force applied to the ball valve 176 by the lower valve actuating sleeve 178, when the ball valve 176 is to be opened by moving the ball valve from the position of FIG. 9b to the position of FIG. 10b, as the upper valve actuating and sealing sleeve 185 is forced downwardly. When the over-riding control fluid pressure is relieved, the pressure of production fluid acts, to close the ball valve 176, across the combined areas of the upper sleeve or piston section 187 and the secondary sleeve 190 when the latter shoulders at 1900, as seen in FIG. 10a.

Preferably, the valve assembly includes resilient sealing means 202 engageable with the ball valve 176 when it is in the closed position. In the embodiment now being described, the resilient sealing means 202 comprises a seal carrier ring 203 having an annular elastomeric seal ring 204 engageable with the ball valve 176 externally of the seating surface 186 at the lower end of the sleeve 185. The seal carrier ring 203 is normally biased downwardly by a coiled compression spring 205 which seats against a seating ring 206 carried within the valve body 136.

The respective valve assemblies V1 and V2 are full opening valve assemblies through which remedial operations can be performed when the ball valve is opened. The valve assembly, as shown, is more particularly the subject matter of the companion application Ser. No. 286,151, filed September 5, 1972.

In order to provide a ball valve 176 of maximum diameter, the ball valve 176 is installed in the body 136 through a side opening 207 which is closed by a valve supporting closure member 208 which fits within the opening 207, and is sealed therein by a suitable seal ring 209. Referring again to FIG. 2b, it will be noted that the closure and valve support member 208 is adapted to be secured to the valve body 136 by a suitable number of fasteners 210, as best seen in FIG. 8, the closure member 208 includes a guide section 211 having a bore 212 through which the tubular member 140 rotatably extends.

In order to support the ball valve 176 and cause rotation thereof in response to movement of the ball longitudinally between the sleeves 185 and 178, the valve supporting member 208 has a pin or lug 213 projecting therefrom in aligned opposition to a corresponding pin or lug 214 carried within the valve body 136, and the ball valve 176 has at its opposite sides corresponding slots 215 in which the respective pins or lugs 213 and 214 are engageable for rotating the ball valve 176 between the opened and closed positions, as best illustrated in FIGS. 16 through 19. In these views, the side of the ball valve 176 supported by the closure 208 is illustrated, but similar structure will be understood to be located at the other side of the ball valve, also. In FIG. 16, the valve is shown fully closed and sealed by the sleeves 178 and 185 as well as by the resilient sealing means 202. In FIG. 17, the valve 176 has been shifted downwardly away from the resilient seal means 202 through an initial increment of non-rotative longitudinal movement. In FIG. 18, the ball valve 176 is in the partially opened position. In FIG. 19, the ball valve 176 is in the fully opened position. i

More particularly, the ball valve member 176 on each of its opposite sides has a chordal flat surface 216 adjacent to the diametrically opposite portions of the body 136 and the support 208. The slot 215 extends radially with respect to the axis of rotation to the ball valve member 176, and at right-angularly spaced locations, the ball face 190 is recessed to form a stop surface 217 and a stop surface 218 cooperable with fixed stop lug surfaces 217a and 218a on the closure 208 to limit rotation of the ball 176 between the extremes of FIG. 16 and FIG. 19. When the ball valve member 176 is in the position of FIG. 16, the stop surface 217 engages the vertical stop surface 217a, thereby limiting rotation of the valve member 176 to the position at which the valve is open. The stop surface 218 engages the stop surface 218a, as shown in FIG. 19 to limit rotation of the valve member 176 to'the position at which the valve is closed. Such rotation between the open and closed positions is caused by longitudinal or vertical movement of the valve member 176 relative to the body 136. As previously indicated, the .ball member 176 is actuated or shifted longitudinally by longitudinal movement of the upper actuator sleeve 185 and the lower actuator sleeve 178, as indicated by the arrows in FIGS. 17 and 18. The slot 215 is formed .in such a manner as to cause such rotation of the valve member 176 as the latter moves vertically or longitudinally within the body 136. Thus, as seen in FIG. 16, the slot 215 is formed on the valve member 176 by opposed walls which are disposed at a right angle to one another and designated 215a and 2l5b and which respectively are parallel to the stop surfaces 217a and 2171). At the apex of the angle defined between the walls 215a and 215b, the slot opens radially inwardly at 2156. Thus, the relationship between the pin 213 and the wall 215b is such that the ball valve 176 will be rotated from the position of FIG. 16 to the position of FIG. 19 when the valve member 176 moves downwardly relative to the pin 213, and, conversely, the flat wall 215a will engage the pin 213 and rotate the ball valve member from the position of FIG. 19 to the position of FIG. 16 upon upward movement of the valve member 176. However, it will be noted that when the valve member 176 is in the position of FIG. 19,- the pin 213 clears the flat wall 215a so as to allow freedom of longitudinal movement of the ball valve 176 after -the stop surface 218 engages the stop 218a, and correspondingly limited free downward movement of the ball valve 176 is permitted when the ball valve is open, as seen in FIG. 16, where the pin 213 clears the slot wall 215a, and the stop surface 217 engages the stop 217a. Such free or lost motion connection of the ball valve 176 and the rotating pin 213 relieves the connection of damaging forces when the ball valve is in either of its closed positions, and in addition saves the resilient seal 202 from relative rotative movement of the ball valve 176.

When the ball valve 176 is closed and is to be opened by applying control fluid pressure to the piston chamber 195, there may be substantial differential pressure across the valve tending to hold it closed, and in order to equalize the pressure across the valve, equalizing valve means 220 are provided, as best seen in FIG. 14, for establishing communication between a port 221 below the ballvalve, 176 (FIG. 9b) and a port 228 in the valve 176 (FIG. 9a), via the elongated passage 223 in the valve body 136. The port 221 communicates with the annular space 224 between the body 136 and the lower valve actuating sleeve 178 which communicates with the passage through the tubular member 134 through radial ports 225 in the upper end of the member 134, when the valve 176 is closed, as seen in FIG. 9b. Above the ball valve 176, the skirt 198 of the upper valve body section 136a has a number of radial ports 226 communicating between the flow passage through the valve assembly and an annulus 227 which in turn communicates through a port 228 with a chamber 229 of the equalizing valve means 220. The equalizing valve chamber 229 is provided by a tubular insert 230 retained in a bore 231 in the body 136 by a sealing plug 232. Seals 234 and 234a on the insert 230 engage in the bore 231 and a reduced bore 235. A valve member 236 is reciprocable in the insert 230 and has its lower end 237 provided with a seal 238 slideably engaging within the insert 230 below inlet ports 239 in the insert which establish communication between the port 228 and the valve chamber 229, so that above the seal 238, the chamber 229 is exposed to the flow passage through the upper valve body 136a. At the upper end of the equalizing valve member 236 is a head 240 engageable with a seat 241 under the influence of pressure below the ball valve 176 supplied to an inlet chamber 242, above the head 240, via the passage 223 and via a radial port 243 in the body 136 and ports 244 in the insert 230. A rod 245 slideably extends downwardly through thelower end of the insert 230 and into the bore 235, and a coiled spring 246 engages the insert 203 and an adjustable spring seat 247 on the rod to provide a downward bias closing the head 240 against the seat 

1. In a shutoff valve for wells, said valve including an elongated valve body having a flow passage therethrough, valve means in said body including a valve element shiftable between a first position closing said passage and a second position at which said passage is open, means for shifting said valve member from said second position to said first position, and control fluid pressure responsive means for shifting said valve member from said first position to said second position, said control fluid pressure responsive means including means defining a control fluid pressure chamber, valve operating means having an actuator sleeve having a piston exposed to control fluid pressure in said chamber, and auxiliary shifting means operable by a shifting tool moveable into said passage for shifting said actuator sleeve to move said valve element to said second position from said first position.
 2. In a shutoff valve as defined in claim 1, said auxiliary shifting means having lock means for holding said actuator sleeve in a position holding said valve element in said second position.
 3. In a shutoff valve as defined in claim 1, said auxiliary shifting means having lock means for holding said actuator sleeve in a position holding said valve element in said second position, and means in said body forming a seat for an auxiliary shutoff valve in said passage.
 4. In a shutoff valve as defined in claim 1, said auxiliary shifting means comprising a shifting sleeve shiftably disposed in said passage and movable to shift said actuator sleeve to a position at which said valve element is in said second position, said shifting sleeve forming a wall of said pressure chamber when in an initial position and allowing communication between said pressure chamber and said passage when said shifting sleeve moves said actuator sleeve to a position at which said valve element is in said second position, and seat means in said body forming spaced seals for an auxiliary shutoff valve in said passage to apply control fluid pressure from said pressure chamber to said auxiliary shutoff valve.
 5. In a shutoff valve as defined in claim 1, said auxiliary shifting means comprising a shifting sleeve shiftably disposed in said passage and movable to shift said actuator sleeve to a position at which said valve element is in said second position, said shifting sleeve forming a wall of said pressure chamber when in an initial position and allowing communication between said pressure chamber and said passage when said shifting sleeve moves said actuator sleeve to a position at which said valve element is in said second position, and seat means in said body forming spaced seals for an auxiliary shutoff valve in said passage to apply control fluid pressure from said pressure chamber to said auxiliary shutoff valve, said body having a bypass passage communicating with said flow passage at opposite sides of said valve element, bypass valve means normally closing said bypass passage and operable by the pressure of control fluid in said pressure chamber to open said bypass passage, and check valve means for preventing flow of control fluid from said pressure chamber through said bypass passage when said shifting sleeve moves said actuator sleeve to said position at which said valve member is in said second position.
 6. In a shutoff valve as defined in claim 1, said auxiliary shifting means including a shifting sleeve in said passage shiftable from an initial position to a position holding said valve element in said second position, and including latch means for holding said shifting sleeve in said latter position.
 7. In a shutoff valve as defined in claim 1, said auxiliary shifting means including a shifting sleeve in said passage shiftable from an initial position to a position holding said valve element in said second position, and including latch means for holding said shifting sleeve in said latter position, said latch means including a resilient latch ring interposed between said body and said shifting sleeve, one of said shifting sleeve and said body having latch elements engageable by said latch ring when said shifting sleeve is in said latter position.
 8. In a shutoff valve as defined in claim 1, said auxiliary shifting means including a shifting sleeve in said passage shiftable from an initial position to a position holding said valve element in said second position, and including latch means for holding said shifting sleeve in said latter position, said latch means including a resilient latch ring interposed between said body and said shifting sleeve, one of said shifting sleeve and said body having latch elements engageable by said latch ring when said shifting sleeve is in said latter position and the other of said shifting sleeve and said body having means for forcing said latch ring into locking engagement with said latch elements to hold said shifting sleeve in said latter position.
 9. In a shutoff valve as defined in claim 1, said auxiliary shifting means including a shifting sleeve in said passage shiftable from an initial position to a position holding said valve element in said second position, and auxiliary shifting tool means engageable with said shifting sleeve to move said shifting sleeve to its latter position.
 10. In a shutoff valve as defined in claim 1, said auxiliary shifting means having lock means for holding said actuator sleeve in a position holding said valve element in said second position, and means in said body forming a seat for an auxiliary shutoff valve in said passage including sealing bores at axially spaced locations spanning said control fluid pressure chamber.
 11. In a shutoff valve as defined in claim 1, said auxiliary shifting means comprising a shifting sleeve shiftably disposed in said passage and movable to shift said actuator sleeve to a position at which said valve element is in said second position, said shifting sleeve forming a wall of said pressure chamber when in an initial position and allowing communication between said pressure chamber and said passage when said shifting sleeve moves said actuator sleeve to a position at which said valve element is in said second position, and seat means in said body forming spaced seals for an auxiliary shutoff valve in said passage to apply control fluid pressure from said pressure chamber to said auxiliary shutoff valve including sealing bores at axially spaced locations spanning said control fluid pressure chamber.
 12. In a shutoff valve for wells, said valve including an elongated valve body having a flow passage therethrough, valve means in said body including a valve element shiftable between a first position closing said passage and a second position at which said passage is open, means for shifting said valve member from said second position to said first position, and control fluid pressure responsive means for shifting said valve member from said first position to said second position, said control fluid pressure responsive means including means defining a control fluid pressure chamber, valve operating means having an actuator sleeve having a piston exposed to control fluid pressure in said chamber, and auxiliary shifting means for shifting said actuator sleeve to move said valve element to said second position from said first position by application of pressure to the flow passage above said auxiliary shifting means.
 13. In a shutoff valve for wells as defined in claim 10, said auxiliary shifting means comprising a shifting sleeve shiftably disposed in said passage and movable to shift said actuator sleeve to a position at which said valve element is in said second position, and a shifting tool responsive to said application of pressure to the flow passage above Said auxiliary shifting means for shifting said shifting sleeve.
 14. In a shutoff valve for wells as defined in claim 12, said auxiliary shifting means comprising a shifting sleeve shiftably disposed in said passage and movable to shift said actuator sleeve to a position at which said valve element is in said second position, said shifting sleeve forming a wall of said pressure chamber when in an initial position and allowing communication between said pressure chamber and said passage when said shifting sleeve moves said actuator sleeve to a position at which said valve element is in said second position, and seat means in said body forming spaced seals for an auxiliary shutoff valve in said passage to apply control fluid pressure from said pressure chamber to said auxiliary shutoff valve.
 15. In a shutoff valve for wells as defined in claim 12, said auxiliary shifting means comprising a shifting sleeve shiftably disposed in said passage and movable to shift said actuator sleeve to a position at which said valve element is in said second position, said shifting sleeve forming a wall of said pressure chamber when in an initial position and allowing communication between said pressure chamber and said passage when said shifting sleeve moves said actuator sleeve to a position at which said valve element is in said second position, seat means in said body forming spaced seals for an auxiliary shutoff valve in said passage to apply control fluid pressure from said pressure chamber to said auxiliary shutoff valve, and an auxiliary shutoff valve assembly in said passage and having spaced sealing means engaged with said spaced seals in said body, said auxiliary shutoff valve means having a fluid inlet between said spaced sealing means for the admission of control fluid pressure from said pressure chamber.
 16. In a shutoff valve for wells as defined in claim 12, said auxiliary shifting means comprising a shifting sleeve shiftably disposed in said passage and movable to shift said actuator sleeve to a position at which said valve element is in said second position, said shifting sleeve forming a wall of said pressure chamber when in an initial position and allowing communication between said pressure chamber and said passage when said shifting sleeve moves said actuator sleeve to a position at which said valve element is in said second position, and seat means in said body forming spaced seals for an auxiliary shutoff valve in said passage to apply control fluid pressure from said pressure chamber to said auxiliary shutoff valve including sealing bores at axially spaced locations spanning said control fluid pressure chamber.
 17. In a shutoff valve for wells as defined in claim 12, said auxiliary shifting means comprising a shifting sleeve shiftably disposed in said passage and movable to shift said actuator sleeve to a position at which said valve element is in said second position, said shifting sleeve forming a wall of said pressure chamber when in an initial position and allowing communication between said pressure chamber and said passage when said shifting sleeve moves said actuator sleeve to a position at which said valve element is in said second position, seat means in said body forming spaced seals for an auxiliary shutoff valve in said passage to apply control fluid pressure from said pressure chamber to said auxiliary shutoff valve, and an auxiliary shutoff valve assembly in said passage and having spaced sealing means engaged with said spaced seals in said body, said auxiliary shutoff valve means having a fluid inlet between said spaced sealing means for the admission of control fluid pressure from said pressure chamber, said spaced seals and spaced sealing means spanning said control fluid pressure chamber. 